Valves For Regulating Downhole Fluids Using Contactless Actuation

ABSTRACT

A contactless valve actuation system includes a conduit, which may be a tubing segment in drill string or production string. The system includes a valve including a sealing member that is movable between an open position and a closed position. The system also includes a valve actuator coupled to the valve. The valve actuator is operable to move the sealing member between the open position and the closed position to open and close the valve. The valve actuator includes a sensor and a controller configured to generate a control signal in response to the sensor detecting an actuation signal generator. The system also includes a pump that is fluidly-coupled to the conduit. The pump is operable to convey fluid containing the actuation signal generator through the conduit.

TECHNICAL FIELD

The present disclosure relates generally to the recovery of subterraneandeposits, and more specifically to an actuator used to open or closevalves in a production string.

BACKGROUND

Crude oil and natural gas occur naturally in subterranean deposits andtheir extraction includes drilling a well. The well provides access to aproduction fluid that often contains crude oil and natural gas. Drillingof the well generally involves deploying a drill string into aformation. The drill string includes a drill bit that removes materialfrom the formation as the drill string is lowered to form a wellbore.After drilling and prior to production, a casing may be deployed in thewellbore to isolate portions of the wellbore wall and prevent theingress of fluids from parts of the formation that are not likely toproduce desirable fluids. After completion, a production string may bedeployed into the well to facilitate the flow of desirable fluids fromproducing areas of the formation to the surface for collection andprocessing.

A variety of packers and other tools may operate in the wellbore to fixthe production string relative to a casing or wellbore wall, and mayalso function to isolate production zones (also referred to as“intervals”) of the well so that hydrocarbon-rich fluids are collectedfrom the wellbore instead of undesirable fluids (such as water). Thesepackers and tools may operate in a wide variety of downholeenvironments, including extreme downhole environments having very highpressures and very high temperatures.

Valves may be incorporated into the production string at intervalsbetween packers to allow or cease flow into the production string fromthe production zone that abuts the wellbore between the packers, and forother purposes. Downhole valves may also be included in drilling toolstrings to divert drilling fluid to, for example, facilitate a loggingwhile drilling or measurement while drilling measurement or sampling.Downhole valves may be valves may be actuated by using pressure pulsesor by transmitting a control signal directly to a valve actuator using ahydraulic or electronic control line.

BRIEF DESCRIPTION OF THE DRAWINGS

Illustrative embodiments of the present disclosure are described indetail below with reference to the attached drawing figures, which areincorporated by reference herein and wherein:

FIG. 1 is a schematic, elevation view with a portion shown incross-section of a production system that includes a downhole valveincluding a contactless actuator;

FIG. 2A is a schematic, elevation view with a portion shown incross-section of a drilling system that includes a valve including acontactless actuator, wherein the system is deployed in a subterraneanwell;

FIG. 2B is a schematic, elevation view with a portion shown incross-section of a drilling system that includes a valve including acontactless actuator, wherein the system is deployed in a subsea well;

FIG. 3 is a detail, cross-sectional view of the downhole valve of FIG.1;

FIG. 4 is a schematic diagram of the downhole valve of FIG. 3; and

FIG. 5 is a schematic flowchart of an illustrative method forcontactless actuation of a downhole valve, according to an embodiment.

The illustrated figures are only exemplary and are not intended toassert or imply any limitation with regard to the environment,architecture, design, or process in which different embodiments may beimplemented.

DETAILED DESCRIPTION OF ILLUSTRATIVE EMBODIMENTS

In the following detailed description of the illustrative embodiments,reference is made to the accompanying drawings that form a part hereof.These embodiments are described in sufficient detail to enable thoseskilled in the art to practice the invention, and it is understood thatother embodiments may be utilized and that logical structural,mechanical, electrical, and chemical changes may be made withoutdeparting from the scope of the invention. To avoid detail not necessaryto enable those skilled in the art to practice the embodiments describedherein, the description may omit certain information known to thoseskilled in the art. The following detailed description is, therefore,not to be taken in a limiting sense, and the scope of the illustrativeembodiments is defined only by the appended claims.

In the drawings and description that follow, like parts are typicallymarked throughout the specification and drawings with the same referencenumerals or coordinated numerals. The drawing figures are notnecessarily to scale. Certain features of the invention may be shownexaggerated in scale or in somewhat schematic form and some details ofconventional elements may not be shown in the interest of clarity andconciseness.

As noted above, downhole valves are typically actuated using electronicor hydraulic control lines that utilize a line connection to a surfacecontroller. The illustrative embodiments described herein relate to adownhole valve system having a contactless actuator, which mayincorporate a number of signal generators and receivers to open andclose a downhole valve without utilizing a dedicated control line.

Unless otherwise specified, any use of any form of the terms “connect,”“engage,” “couple,” “attach,” or any other term describing aninteraction between elements is not meant to limit the interaction todirect interaction between the elements and may also include indirectinteraction between the elements described. In the following discussionand in the claims, the terms “including” and “comprising” are used in anopen-ended fashion, and thus should be interpreted to mean “including,but not limited to”. Unless otherwise indicated, as used throughout thisdocument, “or” does not require mutual exclusivity.

The various characteristics mentioned above, as well as other featuresand characteristics described in more detail below, will be readilyapparent to those skilled in the art with the aid of this disclosureupon reading the following detailed description of the embodiments, andby referring to the accompanying drawings. Other means may be used aswell.

Referring now to the figures, FIG. 1 shows an illustrative embodiment ofa system 100 including a valve assembly 102 that is actuated using acontactless actuator. The system 100 is depicted in a schematic,elevation view with a portion shown in cross-section. The system 100includes a rig 108 atop a surface 110 of a well 112. Beneath the rig108, a wellbore 106 is formed within a geological formation 114, whichis expected to produce hydrocarbons in the form of production fluid 104.The wellbore 106 may be formed in the geological formation 114 using adrill string that includes a drill bit to remove material from thegeological formation 114. The wellbore 106 of FIG. 1 is shown as beingnear-vertical, but may be formed at any suitable angle to reach ahydrocarbon-rich portion of the geological formation 114. In someembodiments, the wellbore 106 may follow a vertical, partially-vertical,angled, or even a partially-horizontal path through the geologicalformation 114.

A production tool string 116 is deployed from the rig 108, which may bea drilling rig, a completion rig, a workover rig, or another type ofrig. The rig 108 includes a derrick 118 and a rig floor 120. Theproduction tool string 116 extends downward through the rig floor 120,through a fluid diverter 122 and blowout preventer 124 that provide afluidly sealed interface between the wellbore 106 and externalenvironment, and into the wellbore 106 and geological formation 114.Coupled to the fluid diverter 122 is a pump 128 coupled to a controlsystem 126. The pump 128 is operational to deliver or receive fluidthrough an internal bore of the production tool string 116 by applying apositive or negative pressure to the internal bore. The pump 128 mayalso deliver or receive fluid through an annulus 130 by applying apositive or negative pressure to the annulus 130. The annulus 130 isformed between an exterior of the production tool string 116 and awellbore casing 132 or between the wall of the wellbore 106 and theexterior of the production tool string 116 when production tool string116 is disposed within the wellbore 106.

Following formation of the wellbore 106, the production tool string 116may be equipped with tools and deployed within the wellbore 106 toprepare, operate, or maintain the well 112. Specifically, the productiontool string 116 may incorporate tools that are actuated after deploymentin the wellbore 106, including without limitation bridge plugs,composite plugs, cement retainers, high expansion gauge hangers,straddles, and packers. Actuation of such tools may result in centeringthe production tool string 116 within the wellbore 106, anchoring theproduction tool string 116, isolating a segment of the wellbore 106, orother functions related to positioning and operating the production toolstring 116. In the illustrative embodiment shown in FIG. 1, theproduction tool string 116 is depicted with a packer 134 within aproduction zone of the geological formation 114. The packer 134 isconfigured to provide a fluid seal between the production tool string116 and the wellbore 106, thereby defining an interval or productionzone adjacent the production tool string 116. Packers 134 are typicallyused to prepare the wellbore 106 for hydrocarbon production duringoperations such as fracturing of the formation or for service duringformation of the well during operations such as acidizing or cementsqueezing.

Below the packer 134 is the valve assembly 102 that controls the flow ofproduction fluid 104 into the production string 116. The illustrativevalve assembly 102 is coupled to, or includes, an actuator that may betriggered using a contactless signal generator, as described in moredetail below. The signal generator may be a device that emits a lightsource, a magnetic field, a radio signal, an acoustic signal, aradioactive signal, or a combination thereof.

In other embodiments, the actuator may be used to actuate tools orassemblies within the production tool string 116, such as the packer 134or other tools. In an embodiment, prior to actuation of the valveassembly 102 or other tool, fluid may be provided to the wellbore fromthe pump 128. The pump 128 is coupled to the surface controller 126,which may include a signal generator dispenser or “hopper” thatdispenses one or more signal generators into a fluid that is beingprovided downhole in response to a user generated or computer generatedinstruction to actuate the valve assembly 102 or other tool. Fluid maybe circulated downhole for various purposes. In an embodiment, thesignal generators may be a clear ball or another suitable type ofparticle that includes a signal generator to generate any one of thetypes of signals described above.

In operation, the valve assembly 102 or other tool may be actuated bythe control system 126 dispensing a signal generator into the wellbore126, which may be detected by a downhole detector that iscommunicatively coupled to the actuator. Detection of the signalgenerator by the detector may result in actuation of the valve or otherdownhole device. The detector may be selected based on the type ofsignal generated by the signal generator. For example, a photocell maybe used to detect a light source, a magnetic or electromagnetic fieldsensor may be used to detect a magnetic field, an antenna may be used todetect a radio signal, a hydrophone or similar device may be used todetect an acoustic signal, and a radioactive isotope identificationdevice may be used to detect a radioactive signal.

It is noted that while the operating environment shown in FIG. 1 relatesto a stationary, land-based rig for raising, lowering, and setting theproduction tool string 116, in alternative embodiments, mobile rigs,wellbore servicing units (e.g., coiled tubing units, slickline units, orwireline units), and the like may be used to lower the production toolstring 116. Furthermore, while the operating environment is generallydiscussed as relating to a land-based well, the systems and methodsdescribed herein may instead be operated in subsea well configurationsaccessed by a fixed or floating platform.

FIG. 2A shows an alternative deployment of a valve assembly 270including, or coupled to, a contactless actuator and deployed in adrilling system 200. The drilling system 200 is deployed in a well 202including a wellbore 206 that extends from a surface 210 of the well 202to or through a subterranean formation 214. The well 202 is illustratedonshore in FIG. 2A with a drill string 216 deployed to operate a drillbit 222 to form the wellbore 206. In another embodiment, the drillingsystem 200 and associated valve assembly 270 and contactless actuatormay be deployed in a sub-sea well 201 accessed by a fixed or floatingplatform 221, as shown in FIG. 2B. FIGS. 2A and 2B each illustratepossible implementations of such systems, and while the followingdescription of the valve assembly 270 and contactless actuator focusesprimarily on the use of the valve assembly 270 and a related controlsystem 226 with the onshore well 202 of FIG. 2A, the valve assembly 270and contactless actuator may be used instead in the well configurationillustrated in FIG. 2B, as well as in other well configurations where itis desirable to actuate a downhole valve or other tool using acontactless actuator. Similar components in FIGS. 2A and 2B areidentified with similar reference numerals.

The well 202 is formed by a drilling process in which a drill bit 222 isturned by the drill string 216 to remove material from the formation andform the wellbore 206. The drill string 216 extends from the drill bit222 at the bottom of the wellbore 206 to the surface 210 of the well202, where it is joined with a kelly 228. The drill string 216 may bemade up of one or more connected tubes or pipes of varying or similarcross-section. The drill string 216 may refer to the collection of pipesor tubes as a single component, or alternatively to the individual pipesor tubes that comprise the string. The term drill string is not meant tobe limiting in nature and may refer to any component or components thatare capable of transferring rotational energy from the surface of thewell to the drill bit 222. In several embodiments, the drill string 216may include a central passage disposed longitudinally in the drillstring 216 and capable of allowing fluid communication between thesurface 210 of the well and downhole locations.

At or near the surface 210 of the well 202, the drill string 216 mayinclude or be coupled to the kelly 228. The kelly 228 may have a square,hexagonal or octagonal cross-section. The kelly 228 is connected at oneend to the remainder of the drill string 216 and at an opposite end to arotary swivel 232. The kelly 228 passes through a rotary table 236 thatis capable of rotating the kelly 228 and thus the remainder of the drillstring 216 and drill bit 222. The rotary swivel 232 allows the kelly 228to rotate without rotational motion being imparted to the rotary cable242. A hook 238, the cable 242, a traveling block (not shown), and ahoist (not shown) are provided to lift or lower the drill bit 222, drillstring 216, kelly 228 and rotary swivel 232. The drill string 216 may beraised or lowered as needed to add additional sections of tubing to thedrill string 216 as the drill bit 222 advances, or to remove sections oftubing from the drill string 216 if removal of the drill string 216 anddrill bit 222 from the well 202 are not desired.

In normal operation, drilling fluid 204 is stored in a drilling fluidreservoir 244 and pumped into an inlet conduit 252 using a pump 229, orplurality of pumps disposed along the inlet conduit 252. The drillingfluid 204 passes through the inlet conduit 252 and into the drill string216 via a fluid coupling at the rotary swivel 232. The drilling fluid204 is circulated into the drill string 216 to maintain pressure in thedrill string 216 and wellbore 206 and to lubricate the drill bit 222 asit cuts material from the formation 214 to deepen or enlarge thewellbore 206. After exiting the drill string 216, the drilling fluid 204carries cuttings from the drill bit 222 back to the surface 210 throughan annulus 230 formed by the space between the inner wall of thewellbore 206 and outer wall of the drill string 216. At the surface 210,the drilling fluid 204 exits the annulus 230 and is carried to arepository. Where the drilling fluid 204 is recirculated through thedrill string 216, the drilling fluid 204 may return to the drillingfluid reservoir 244 via an outlet conduit 264 that couples the annulus230 to the drilling fluid reservoir 244. The path that the drillingfluid 204 follows from the reservoir 244, into and out of the drillstring 216, through the annulus 230, and to the repository may bereferred to as the fluid flow path.

At various times during the formation of the well 202, it may bedesirable to halt the flow of fluid to the drill bit 222 whilemaintaining fluid flow throughout the remainder of the system. Forexample, it may be desirable to halt fluid flow adjacent alogging-while-drilling (LWD) or measurement-while-drilling (MWD) sensor,such as a sampling chamber, thermometer, camera, or other device. Torepresent a LWD or MWD tool, a measurement module 272 is depicted asbeing downhole from the valve assembly 270. The valve assembly 270 maybe oriented in the drill string 216 such that when the valve assembly270 is in a first orientation, the drilling fluid 204 is directeddownward through the downhole measurement module 272 to the drill bit222, and when the valve is in a second orientation, the drilling fluidbypasses the downhole measurement module 272 and is directed into theannulus 230 and back toward the surface. This configuration may alsofacilitate the continuous circulation of drilling fluid 204 through thewellbore 206 even when operation of the drill bit 222 is suspended.

As described in more detail below with regard to FIGS. 3 and 4, thevalve assembly 270 includes a contactless actuator that may be used tooperate the valve assembly 270 without an established electronic orhydraulic control line. Further, the valve assembly 270 is discussedmerely as an illustrative system and it is noted that the contactlessactuator may be instead used to actuate other types of downhole tools,including, for example, a measurement module 272.

FIG. 3 shows a detail view, in partial cross-section, of a valve andcontactless actuator assembly 310, as indicated in FIG. 3. In severalembodiments, the valve assembly 310 is the valve assembly 102 of FIG. 1.In other embodiments, the valve assembly 310 is the valve assembly 270of FIGS. 2A and 2B. The valve assembly 310 includes an actuator 332,which, as described in more detail below, may be a contactless actuatorthat actuates a downhole tool, such as a valve 330. The valve 330 may bea ball valve as shown or any other suitable type of valve, such as asleeve valve. The actuator 332 is coupled to a hydraulic pump 334, whichis also coupled to a movable member 336 of the valve 330. When using aball valve, the valve 330 includes a sealing member, such as a valveball 350 having an aperture 352 that allows fluid to flow through thevalve 330 when the valve 330 is open and ceases fluid flow when thevalve 330 is closed. In another embodiment the valve 330 may include at-valve that allows fluid to flow through the tubing segment thatincludes the valve 330 when open and diverts fluid flow outside of thetubing segment when closed.

In an illustrative embodiment, the actuator 332 includes a passivedetector or sensor 315 that detects one or more signals generated by asignal generator. As described above, the signal generator may be adevice that emits a light source, such as a clear ball with an embeddedor enclosed LED, a permanent magnet, a radio-frequency identification(RFID) tag, a mud-pulse telemetry broadcasting device or speaker, or anacoustic signal, a radioactive isotope, or a combination thereof. Thedetector or sensor 315 may be selected based on the type of signalgenerated by the signal generator. For example, the sensor 315 mayinclude a photocell, a magnetic or electromagnetic field sensor, anantenna, a hydrophone, a radioactive isotope identification device orradiation detector, or any other suitable sensor 4.

Upon detection of the signal generator by the sensor 315, the actuator332 causes the hydraulic pump 334 to actuate the movable member 336 ofthe valve 330, which turns the valve ball 350 to close the valve 330 andprevent flow therethrough. Closing of the valve 330 may facilitate theclosing of a zone of the well or enable the buildup of pressure in thetool string that includes the valve 330 so that, for example, a packermay be set up-hole from the valve 330. Similarly, opening of the valve330 facilitates the renewal of flow through the valve 330, either to orfrom a downhole location.

In one embodiment, the actuator 332 includes a power source, controller,memory, a power source, an actuating member, and a sensor. The sensormonitors the fluid within a predetermined range of the actuator 332 forthe presence of one or more signal generators, and is operable to detectthe presence of a signal generator and the frequency at which signalgenerators are detected as a function of time. The controller of theactuator 332 is operable to execute instructions stored in the memoryfor actuating the valve 330 based on conditions detected by the sensor.The power source, which may include a battery, provides a local power tothe components of the actuator 332, including the sensor, controller,and actuating member. In an embodiment, the actuating member is a motorand gearbox that are coupled to and configured to operate the hydraulicpump. In another embodiment, the actuating member may be a solenoid. Ineither case, the actuator 332 and its constituent components arearranged about the periphery of the assembly 310 to avoid interferencewith fluid flowing along a fluid flow path through the valve 330 andassembly 310.

In response to the detection of a signal generator by the sensor 315,the controller of the actuator 332 will operate the actuating member ofthe actuator 332 to open or close the valve 330 in accordance with theoperating instructions of the actuator 332. The actuator 332 therebyoperates the hydraulic pump 334, which provides at least one hydrauliccontrol line to the movable member 336. In an embodiment, at least onehydraulic control lines extends from the pump 334 to the movable member336 of the valve 330.

In an embodiment, the valve 330 comprises a substantially cylindricalbody having an axial bore running therethrough to facilitate the flow offluids therethrough. The body may include ports or an access sleeve thatconnects the actuator to the movable member 336. In an embodiment, themovable member 336 includes a valve ball 350 arranged on a pivot so thatthe valve ball 350 can rotate within the bore to open and close thevalve 330. To facilitate flow through the valve 330 when open, the valveball 350 includes an aperture running therethrough, which is sized tomatch the diameter of the bore. The movable member 336 may also includea ball arm that is operated with a piston that is translated back andforth with the hydraulic pump to open and close the valve 330. A sealingarrangement may be used between the valve ball 350 and its housing toprevent fluid leakage through the valve 330. In a similar embodiment,the valve 330 may instead be formed from concentric sleeves havingoverlapping flow ports that are moved in and out of alignment bytranslation of one of the sleeves caused by movement of the piston.

In another embodiment, when the sensor 315 detects a signal generatorand the actuator 332 determines to open the valve 330, the actuator 332operates the hydraulic pump 334 to evacuate the control line to retractthe piston or to provide pressure to a second control line that causesthe piston to retract and open.

FIG. 4 shows a schematic diagram of a contactless actuator system 400including a valve 402 within a downhole tool string, such as aproduction string or a drilling string. A conduit 404 forms a fluid flowpath 406 through the tool string, and includes a sensor 410 operable todetect a signal generator 416 in the conduit 404. The conduit 404 isfluidly coupled to the valve 402. The sensor 410 is coupled to a controlmodule that includes a processor 414, a memory 415, and a power supply412. The power supply 412 may include a battery and/or a downhole powergeneration device, such as a turbine, to generate power to be stored inthe battery. The power supply 412 supplies electrical energy to thesensor 410 and an actuating member 408, which may be a solenoid or amotor coupled to a hydraulic pump, as noted previously. The actuatingmember 408 is coupled to the valve 402, or a movable member thereof, andis thereby operable to open and close the valve 402.

In an embodiment, the actuator system 400 functions as a contactlesstool that replaces a mechanical interface that is typically used to openand close a valve, e.g., in the form of a dropped ball or mechanicalmanipulation of an entire tool string, such as pulling up (close) orpushing down (open) using a collet or shifting tool that is attached tothe end of the tool string. The signal generator may be a magnet, aradioactive source (such as strontium-90, tritium, carbon-14,phosphorus-32, nickel-63, or a combination thereof), and electronicsignal generator such as an RFID tag, or an acoustic sound generator(such as a speaker or projector operable to generate a periodic SONARping). Depending on the selected signal generator, the sensor 410 may bea magnetic field sensor, such as a MEMS magnetic field sensor, aradiation detector or Gieger counter, an antenna or RFID tag reader, ora hydrophone that is configured to detect the signal generator.

The actuator system 400 may be configured to actuate and close the valve402 in response to the sensor 410 detecting a signal generator 416, thesensor 410 detecting a threshold quantity of signal generators 416, orthe passage of a time delay following detection of a signal generator416. Similarly, the actuator system 400 may be configured to actuate andopen the valve 402 in response to the sensor 410 detecting a signalgenerator 416, the sensor 410 detecting a threshold quantity of signalgenerators 416, the passage of a time delay following detection of asignal generator 416, or the passage of time delay following the closingof the valve 402. It is noted that the signal generator 416 may be adiscrete object, such as a ball or small particle deployed in the fluidflow path 406, or a signal generator 416 that is remotely deployed fromthe surface by, for example, a slickline or wireline cable deployedwithin the tool string or wellbore annulus in an area that will bedetected by the sensor 410. Such a signal generator may thereby be acontactless tool that is deployed without a dedicated electricalconnection or power supply to open or close a downhole valve.

In an embodiment, the sensor 410 may also include a pressure sensor andthereby be configured to detect pressure pulses, or brief surges orvariations in the fluid pressure at the sensor location. In such anembodiment, the memory may be provided with instructions for opening orclosing the valve 402 in response to detecting a pressure pulse or asequence of pressure pulses. For example, a timed sequence of pressurepulses may be associated with a command to open the valve 402 and asecond timed sequence of pressure pulses may be associated with acommand to close the valve 402. In such an embodiment, the actuatorsystem 400 will transition to an open state in response to the sensor410 detecting the first timed sequence of pressure pulses and transitionto a closed state in response to the sensor 410 detecting the secondtimed sequence of pressure pulses.

In an embodiment, the sensor 410 may also include a contact sensor orwet connect that is configured to receive an electrical current, and awire delivering the electrical current may be the signal generator. Thewire may be a low voltage wire that is easily provided downhole by aslickline or wireline application. In such an embodiment, the sensor 410may also be configured to receive and transmit the electrical current tothe power supply 412 to charge the battery of the actuator. In anembodiment, the electrical current may thereby facilitate charging of apower supply 412, thereby extending the life of such valves.

In another embodiment, the actuator system 400 or a plurality ofactuators may be coupled to one or more valves or other tools, such aspackers or measuring devices that may also be actuated by such anactuator system 400, three way valves, etc. In such an embodiment, thesensor 410 may include a photo-sensor, or photo-electric cell that isselected to detect a signal generator 416 that is a LED or similar lightsource included in a clear glass or plastic ball that is deployeddownhole. A plurality of such signal generators may be deployeddownhole, each producing a selected different wavelength of light.Correspondingly, a plurality of actuator systems 400 may be configuredto detect different wavelengths of light so that each tool may beactuated by deploying a signal generator 416 that corresponds to thetool. For example, a first valve may be actuated by deploying a signalgenerator 416 that generates a blue light to a sensor 410 of an actuatorthat is configured actuate the valve in response to the detection ofblue light. Similarly, a second tool may be actuated by deploying asignal generator 416 that emits a red light to a sensor 410 of anactuator system 400 that is configured to actuate the tool in responseto detecting red light. Thus, deployment of signal generators 416 thatemit different wavelengths of light or otherwise discernible signals ofthe types described above (such as magnetic, radioactive, and acousticsignals) may be deployed in succession to actuated a plurality of toolswithin a tool string.

In another embodiment, the actuator 332 of FIG. 1 includes the sensor410, the power supply 412, the processor 414, the memory 415, and theactuating member 408 of FIG. 4, and operates in accordance with one ormore of the foregoing embodiments of the contactless actuation system400 of FIG. 4.

Now referring primarily to FIG. 5, a schematic flow chart shown thereindepicts an illustrative method 500 for contactless actuation of adownhole valve, according to an embodiment. The method 500 may be usedwith any of the previous illustrative embodiments. The method 500includes a step 502 of conveying an actuation signal generator into aconduit of a downhole tool using a fluid. In some embodiments, theactuation signal generator is selected from the group consisting of alight source, a magnetic field source, a radioactive source, and anacoustic source. The method 500 also includes a step 504 of monitoringthe conduit for entry of the actuation signal generator. In certainembodiments, the step 504 of monitoring the conduit includes detectingelectromagnetic radiation from a light emitting diode using aphoto-detector. The method 500 involves a decision, represented byinterrogatory 506, to determine if the actuation signal generator hasbeen detected. Such a determination may include detecting a thresholdquantity of actuation signal generators. If the no actuation signalgenerator has been detected, the method 500 returns to the step 504 ofmonitoring the conduit. However, if the actuation signal generator isdetected at the interrogatory 506, the method 500 proceeds to a step 508of actuating the downhole valve. After the step 508 of actuating thedownhole valve, the system may end 510, or return to a point between thestep 502 and the step 504 to wait for further signals to actuate thevalve again. In some embodiments, the method 500 further includes thestep (not shown) of releasing the actuation signal generator in thefluid. This step is typically performed before the step 502 of conveyingthe actuation signal generator.

Although the present invention and its advantages have been disclosed inthe context of certain illustrative, non-limiting embodiments, it shouldbe understood that various changes, substitutions, permutations, andalterations can be made without departing from the scope of theinvention as defined by the appended claims. It will be appreciated thatany feature that is described in connection to any one embodiment mayalso be applicable to any other embodiment.

Example 1

A valve assembly comprising:

-   -   a fluid conduit;    -   a sealing member to open and close the fluid conduit; and    -   an actuator coupled to the sealing member to move the sealing        member from an open position to a closed position, the actuator        comprising a detector;    -   wherein the detector is a passive detector that senses an        actuation signal generator; and    -   wherein the actuator manipulates the sealing member in response        to the detector sensing the actuation signal generator.

Example 2

The valve assembly of Example 1, further comprising a power sourcecoupled to the actuator.

Example 3

The valve assembly of Example 1 or Example 2, further comprising acontroller coupled to the detector, the controller having at least oneprocessor and at least one memory, the at least one processor and the atleast one memory perform logical operations and calculations in relationto the actuation signal generator sensed by the detector.

Example 4

The valve assembly of Example 1 or any of Examples 2-3, wherein thesealing member comprises a ball having a throughbore and movablyarranged within the fluid conduit, the ball movable between the openposition, where the throughbore is axially aligned with the fluidconduit, and the closed position, where the throughbore is perpendicularto the conduit.

Example 5

The valve assembly of Example 1 or any of Examples 2-3, wherein thesealing member comprises a sleeve valve.

Example 6

The valve assembly of Example 1 or any of Examples 2-5, wherein theactuator comprises a hydraulic pump fluidly-coupled to the sealingmember.

Example 7

The valve assembly of Example 1 or any of Examples 2-6, wherein theactuation signal generator is selected from the group consisting of alight source, a magnetic field generator, a radioactive source, and anacoustic signal generator.

Example 8

The valve assembly of Example 1 or any of Examples 2-6, wherein theactuation signal generator comprises a light source and wherein thedetector comprises a photo sensor.

Example 9

The valve assembly of Example 8, wherein the light source comprises atransparent body containing a light emitting diode.

Example 10

A contactless valve actuation system, the system comprising:

-   -   a conduit;    -   a valve fluidly coupled to the conduit, the valve having a        sealing member that is movable between an open position and a        closed position;    -   a valve actuator coupled to the valve, wherein the valve        actuator moves the sealing member between the open position and        the closed position, the valve actuator comprising a sensor and        a controller to generate a control signal in response to the        sensor detecting an actuation signal generator; and    -   a pump fluidly-coupled to the housing, wherein the pump conveys        fluid containing the actuation signal generator through the        conduit of the housing.

Example 11

The system of Example 10, wherein the valve actuator further comprises alocal power source to provide power to a movable member.

Example 12

The system of Example 10 or Example 11, wherein quantities of theactuation signal generator are released into fluid.

Example 13

The system of Example 10 or any of Examples 11-12, wherein thecontroller determines a position of the valve based on a signal receivedfrom the sensor.

Example 14

The system of Example 10 or any of Examples 11-13, wherein the valveactuator comprises a hydraulic pump fluidly-coupled to the valve.

Example 15

The system of Example 10 or any of Examples 11-14, wherein the valvecomprises a ball having a throughbore and movably arranged with theconduit, the throughbore axially-aligned with conduit in the openposition and perpendicular to the conduit in the closed position.

Example 16

The system of Example 10 or any of Examples 11-14, wherein the valve isa sleeve valve.

Example 17

The system of Example 10 or any of Examples 11-16, wherein the actuationsignal generator is selected from the group consisting of a lightsource, a magnetic field source, a radioactive source, and an acousticsource.

Example 18

The system of Example 10 or any of Examples 11-16, wherein the actuationsignal generator comprises a light emitting diode and wherein the sensorcomprises a photo sensor.

Example 19

A method of actuating a valve, the method comprising:

-   -   conveying an actuation signal generator into a conduit of a        downhole tool using a fluid;    -   monitoring the conduit for entry of the actuation signal        generator; and    -   actuating the valve if the actuation signal generator is        detected in the conduit;    -   wherein the valve controls a sealing member within the conduit        thereby regulating fluid flow therethrough.

Example 20

The method of Example 19, further comprising the step of releasing theactuation signal generator into the fluid.

Example 21

The method of Example 19 or Example 20, wherein the actuation signalgenerator is selected from the group consisting of a light source, amagnetic field source, a radioactive source, and an acoustic source.

Example 22

The method of Example 19 or Example 20, wherein the step of monitoringthe conduit comprises detecting electromagnetic radiation from a lightemitting diode using a photo-detector.

It will be understood that the benefits and advantages described abovemay relate to one embodiment or may relate to several embodiments. Itwill further be understood that reference to “an” item refers to one ormore of those items.

The steps of the methods described herein may be carried out in anysuitable order or simultaneous where appropriate. Where appropriate,aspects of any of the examples described above may be combined withaspects of any of the other examples described to form further exampleshaving comparable or different properties and addressing the same ordifferent problems.

It will be understood that the above description of the embodiments isgiven by way of example only and that various modifications may be madeby those skilled in the art. The above specification, examples, and dataprovide a complete description of the structure and use of exemplaryembodiments of the invention. Although various embodiments of theinvention have been described above with a certain degree ofparticularity, or with reference to one or more individual embodiments,those skilled in the art could make numerous alterations to thedisclosed embodiments without departing from the scope of the claims.

What is claimed is:
 1. A valve assembly comprising: a fluid conduit; asealing member to open and close the fluid conduit; and an actuatorcoupled to the sealing member to move the sealing member from an openposition to a closed position, the actuator comprising a detector;wherein the detector is a passive detector that senses an actuationsignal generator; and wherein the actuator manipulates the sealingmember in response to the detector sensing the actuation signalgenerator.
 2. The valve assembly of claim 1, further comprising a powersource coupled to the actuator.
 3. The valve assembly of claim 1,further comprising a controller coupled to the detector, the controllerhaving at least one processor and at least one memory, the at least oneprocessor and the at least one memory perform logical operations andcalculations in relation to the actuation signal generator sensed by thedetector.
 4. The valve assembly of claim 1, wherein the sealing membercomprises a ball having a throughbore and movably arranged within thefluid conduit, the ball movable between the open position, where thethroughbore is axially aligned with the fluid conduit, and the closedposition, where the throughbore is perpendicular to the conduit.
 5. Thevalve assembly of claim 1, wherein the sealing member comprises a sleevevalve.
 6. The valve assembly of claim 1, wherein the actuator comprisesa hydraulic pump fluidly-coupled to the sealing member.
 7. The valveassembly of claim 1, wherein the actuation signal generator is selectedfrom the group consisting of a light source, a magnetic field generator,a radioactive source, and an acoustic signal generator.
 8. The valveassembly of claim 1, wherein the actuation signal generator comprises alight source and wherein the detector comprises a photo sensor.
 9. Acontactless valve actuation system, the system comprising: a conduit; avalve fluidly coupled to the conduit, the valve having a sealing memberthat is movable between an open position and a closed position; a valveactuator coupled to the valve, wherein the valve actuator moves thesealing member between the open position and the closed position, thevalve actuator comprising a sensor and a controller to generate acontrol signal in response to the sensor detecting an actuation signalgenerator; and a pump fluidly-coupled to the housing, wherein the pumpconveys fluid containing the actuation signal generator through theconduit of the housing.
 10. The system of claim 9, wherein the valveactuator further comprises a local power source to provide power to amovable member.
 11. The system of claim 9, wherein quantities of theactuation signal generator are released into fluid.
 12. The system ofclaim 9, wherein the valve actuator comprises a hydraulic pumpfluidly-coupled to the valve.
 13. The system of claim 9 wherein thevalve comprises a ball having a throughbore and movably arranged withthe conduit, the throughbore axially-aligned with conduit in the openposition and perpendicular to the conduit in the closed position. 14.The system of claim 9, wherein the valve is a sleeve valve.
 15. Thesystem of claim 9, wherein the actuation signal generator is selectedfrom the group consisting of a light source, a magnetic field source, aradioactive source, and an acoustic source.
 16. The system of claim 9,wherein the actuation signal generator comprises a light emitting diodeand wherein the sensor comprises a photo sensor.
 17. A method ofactuating a valve, the method comprising: conveying an actuation signalgenerator into a conduit of a downhole tool using a fluid; monitoringthe conduit for entry of the actuation signal generator; and actuatingthe valve if the actuation signal generator is detected in the conduit;wherein the valve controls a sealing member within the conduit therebyregulating fluid flow therethrough.
 18. The method of claim 17, furthercomprising the step of releasing the actuation signal generator into thefluid.
 19. The method of claim 17, wherein the actuation signalgenerator is selected from the group consisting of a light source, amagnetic field source, a radioactive source, and an acoustic source. 20.The method of claim 17, wherein the step of monitoring the conduitcomprises detecting electromagnetic radiation from a light emittingdiode using a photo-detector.